In this paper results from an ongoing research project (HYGATE) are presented, which is performed to reduce the levelized cost of electricity (LCOE) and to increase the CO 2 reduction potential of the solar-hybrid gas turbine plant concept (SHGT). Key improvements are the integration of thermal energy storage and the reduction of the operating temperature of the gas turbine to 950°C. As a result the solar receiver can provide the necessary temperature for solar-only operation of the plant at design pointwithout using the auxiliary burner. Annual performance calculations and an economic analysis of four different plant concepts were performed. Those concepts were analyzed using innovative power block processes. In general, such systems offer reliable and dispatchable power with low specific CO 2 emissions. A substantial decrease of CO 2 emissions has been achieved all along the four variants compared to results of a previous project [1]. Compared to the defined reference molten salt solar tower the solar-hybrid gas turbine plants as of now yield higher plant efficiencies, but have a slightly lower potential for CO 2 reduction. Among the SHGT plants the variants including a bottoming Organic Rankine Cycle (SHORCC and SHORCC-R) achieve the highest efficiencies but have significantly higher LCOE, caused by the high costs of the ORC components which are not yet commercially available in the required dimensions. The solar-hybrid combined cycle plant (SHCC) and solar-hybrid gas turbine plant with quasi isothermal compression and recuperation (SHGT-ICR) perform best among the SHGT plants in terms of LCOE, and can be considered an interesting alternative to molten salt tower plants. Taking into account other factors, such as plant complexity and water consumption, an isothermal solar gas turbine plant shows the most potential advantages. However, the SHCC has the highest technological maturity and is a likely candidate for a future demonstration plant.
Existing solar thermal power plants are based on steam turbine cycles. While their process temperature is limited, solar gas turbine (GT) systems provide the opportunity to utilize solar heat at a much higher temperature. Therefore there is potential to improve the efficiency of future solar thermal power plants. Solar based heat input to substitute fuel requires specific GT features. Currently the portfolio of available GTs with these features is restricted. Only small capacity research plants are in service or in planning. Process layout and technology studies for high solar share GT systems have been carried out and have already been reported by the authors. While these investigations are based on a commercial 10MW class GT, this paper addresses the parameterization of high solar share GT systems and is not restricted to any type of commercial GT. Three configurations of solar hybrid GT cycles are analyzed. Besides recuperated and simple GT with bottoming Organic Rankine Cycle (ORC), a conventional combined cycle is considered. The study addresses the GT parameterization. Therefore parametric process models are used for simulation. Maximum electrical efficiency and associated optimum compressor pressure ratio πC are derived at design conditions. The pressure losses of the additional solar components of solar hybrid GTs have a different adversely effect on the investigated systems. Further aspects like high ambient temperature, availability of water and influence of compressor pressure level on component design are discussed as well. The present study is part of the R&D project Hybrid High Solar Share Gas Turbine Systems (HYGATE) which is funded by the German Ministry for the Environment, Nature and Nuclear Safety and the Ministry of Economics and Technology.
In this paper, the deployment of a newly developed, multipoint, fiber-optic temperature-sensor system for temperature distribution measurements in a 6 MW gas turbine is demonstrated. The optical sensor fiber was integrated in a stainless steel protection cable with a 1.6 mm outside diameter. It included six measurement points, distributed over a length of 110 mm. The sensor cable was mounted in a temperature probe and was positioned radially in the exhaust-gas diffusor of the turbine. With this temperature probe, the radial temperature profiles in the exhaust-gas diffusor were measured with high spatial and temporal resolution. During a test run of the turbine, characteristic temperature gradients were observed when the machine operated at different loads.
In the food industry, there is typically a requirement for electric power, process steam as well as cooling capability. Based on actual requirements of a specific site, a study was performed to define two different Combined Heat and Power (CHP) options and to compare them over a one year period regarding the extent to which they satisfy the operator’s needs. CHP is defined as the sequential generation of two different forms of usable energy from a single fuel source. It is mechanical energy and thermal energy. The mechanical energy may be used either to drive a generator to produce electricity, or to drive rotating equipment such as a compressor. Thermal energy can be used either directly for process applications or indirectly to produce steam, hot water (district heating), or chilled water for cooling purposes. Combined Heat and Power technologies are proven, reliable and cost-effective. MAN can offer different CHP concepts adapted to specific customer requirements. This paper presents the results of a comparative study based on the typical requirements of the food industry. The CHP system has to cover the demand for power, saturated steam at two pressure levels, and cooling. Two different CHP options were studied and compared regarding technical and economic considerations. The first system proposed is based on a MAN’s gas turbine (model: THM1304-10N) in the 10 MW class, a Waste Heat Recovery Unit for steam production and one Absorption Chiller (ammonia/water) for cooling process. A share of the steam produced is used for driving the chiller. The second system includes a combined cycle with MAN’s new MGT6100 gas turbine in the 6 MW class. A Waste Heat Recovery Unit and a back pressure steam turbine with two extractions at two intermediate pressure levels are used. A part of the saturated steam at the outlet of the steam turbine drives the absorption chiller and the remainder is used for the third steam process. For both options, a supplementary firing is also considered. A technical and economical comparison between the two solutions is provided in order to show the advantages and the disadvantages of each system with regard to the requirements of the specified application.
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